Automated telemetry for switching transmission modes of a downhole device

ABSTRACT

In some embodiments, a system including a tool drill string having a downhole device is disclosed. The downhole device includes a memory storing instructions and a downhole processor configured to execute the instructions to operate in a first transmission mode by default. The downhole processor is communicatively coupled to an uphole processor via the first transmission mode. The downhole processor is further to transmit, via a second transmission mode, a message to the uphole processor, determine whether a response is received, via the second transmission mode, from the uphole processor, and responsive to determining the response is received from the uphole processor, switch from the first transmission mode to the second transmission mode.

CROSS-REFERENCE TO RELATED APPLICATIONS

This application is a continuation-in-part of U.S. application Ser. No.16/822,185 filed Mar. 18, 2020 titled “CONTACT MODULE FOR COMMUNICATINGWITH A DOWNHOLE DEVICE”, which claims priority to and is acontinuation-in-part of U.S. application Ser. No. 16/424,183 filed May28, 2019 titled “CONTACT MODULE FOR COMMUNICATING WITH A DOWNHOLEDEVICE”. The present application also claims priority to U.S.Provisional App. No. 63/013,199 filed Apr. 21, 2020 titled “AUTOMATEDTELEMETRY FOR SWITCHING TRANSMISSION MODES OF A DOWNHOLE DEVICE”. Theentire contents of the referenced applications are incorporated hereinby reference in their entirety for all purposes.

TECHNICAL FIELD

The present disclosure relates to drilling systems. More specifically,the present disclosure relates to automated telemetry for switchingtransmission modes of a downhole device.

BACKGROUND

Drilling systems can be used for drilling well boreholes in the earthfor extracting fluids, such as oil, water, and gas. The drilling systemsinclude a drill string for boring the well borehole into a formationthat contains the fluid to be extracted. The drill string includestubing or a drill pipe, such as a pipe made-up of jointed sections, anda drilling assembly attached to the distal end of the drill string. Thedrilling assembly includes a drill bit at the distal end of the drillingassembly. Typically, the drill string, including the drill bit, isrotated to drill the well borehole. Often, the drilling assemblyincludes a mud motor that rotates the drill bit for boring the wellborehole.

Obtaining downhole measurements during drilling operations is known asmeasurement while drilling (MWD) or logging while drilling (LWD). Adownhole device, such as an MWD tool, is programmed with informationsuch as which measurements to take and which data to transmit back tothe surface while it is on the surface. The downhole device is thensecurely sealed from the environment and the high pressures of drillingand put into the well borehole. After the downhole device is retrievedfrom the well borehole, it is unsealed to retrieve data from thedownhole device using a computer. To use the downhole device again, thedevice is sealed and put back into the well borehole. This process ofsealing and unsealing the downhole device is time consuming anddifficult, and if done wrong very expensive to fix, which increases thecost of drilling the well.

SUMMARY

In one embodiment, a system including a tool drill string having adownhole device is disclosed. The downhole device includes a memorystoring instructions and a downhole processor configured to execute theinstructions to operate in a first transmission mode by default. Thedownhole processor is communicatively coupled to an uphole processor viathe first transmission mode. The downhole processor is further totransmit, via a second transmission mode, a message to the upholeprocessor, determine whether a response is received, via the secondtransmission mode, from the uphole processor, and responsive todetermining the response is received from the uphole processor, switchfrom the first transmission mode to the second transmission mode.

In some embodiments, a method may be performed by the downhole processorexecuting any of the operations described herein.

In some embodiments, a tangible, non-transitory computer-readable mediummay store instructions that, when executed, cause a processing device toperform any of the operations of any of the methods disclosed herein.

While multiple embodiments are disclosed, still other embodiments of thepresent disclosure will become apparent to those skilled in the art fromthe following detailed description, which shows and describesillustrative embodiments of the disclosure.

Accordingly, the drawings and detailed description are to be regarded asillustrative in nature and not restrictive.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 is a diagram illustrating a system including a contact moduleconfigured for communicating with a downhole device, according toembodiments of the disclosure.

FIG. 2A is a diagram illustrating the spearpoint contact module engagedby an over shot tool for lifting the spearpoint and the device,according to embodiments of the disclosure.

FIG. 2B is a diagram illustrating a contact module that is configured tobe situated in the middle of a downhole drill string and forcommunicating with the downhole device, according to embodiments of thedisclosure.

FIG. 3 is a diagram schematically illustrating a surface processorconfigured to communicate with the device through a surface connectorand a contact module, such as a spearpoint or another contact module,according to embodiments of the disclosure.

FIG. 4 is a diagram illustrating a spearpoint connected to a device anda surface connector configured to be coupled onto the spearpoint,according to embodiments of the disclosure.

FIG. 5 is a diagram illustrating the spearpoint including at leastportions of the end shaft, the contact shaft, and the latch rod,according to embodiments of the disclosure.

FIG. 6 is an exploded view diagram of the spearpoint shown in FIG. 5,according to embodiments of the disclosure.

FIG. 7 is a diagram illustrating the spearpoint and the device and across-sectional view of the surface connector, according to embodimentsof the disclosure.

FIG. 8 is a diagram illustrating the spearpoint inserted into thesurface connector and/or coupled to the surface connector, according toembodiments of the disclosure.

FIG. 9 is a flow chart diagram illustrating a method of communicatingwith a device, such as a drill string tool, through a contact module,such as a spearpoint contact module, according to embodiments of thedisclosure.

FIG. 10 is a block diagram of various electronic components included inthe contact module, according to embodiments of the disclosure.

FIG. 11 illustrates example operations of a method for operating theprocessor as a network switch, according to embodiments of thedisclosure.

FIG. 12 illustrates example operations of a method for correcting datareceived from the downhole device or the surface processor that includeserrors, according to embodiments of the disclosure.

FIG. 13A is a block diagram of various electronic components included inan electronic control module, according to embodiments of thedisclosure.

FIG. 13B is another block diagram of various electronic componentsincluded in an electronic control module, according to embodiments ofthe disclosure.

FIG. 14 illustrates example operations of a method for performing ahandshake operation to switch transmission modes of a downhole device,according to embodiments of the disclosure.

FIG. 15 illustrates example operations of another method for performinga handshake operation to switch transmission modes of a downhole device,according to embodiments of the disclosure.

DETAILED DESCRIPTION

The present disclosure describes embodiments of a system forcommunicating with a device that is configured to be put down a wellborehole, i.e., a downhole device. The system is used to communicatewith the downhole device at the surface and with the downhole devicephysically connected in the downhole tool drill string, such as an MWDdrill string. The system includes a contact module that is physicallyand electrically coupled to the downhole device in the downhole tooldrill string. The contact module includes at least one externalelectrical contact that is electrically coupled to the downhole devicefor communicating with the downhole device through the at least oneexternal electrical contact. The contact module, including the at leastone external electrical contact and insulators around the at least oneexternal electrical contact, is pressure sealed to prevent drillingfluid and other fluids from invading the interior of the contact module.This prevents the drilling fluid and other fluids from interfering withcommunications between the contact module and the downhole device, suchas by preventing short circuits in the contact module.

The contact module can be situated anywhere in the downhole tool drillstring. In embodiments, the contact module is situated at the proximalend of the downhole tool drill string. In some embodiments, the contactmodule is a spearpoint contact module situated at the proximal end ofthe downhole tool drill string and configured for lifting or raising andlowering the downhole tool drill string. In some embodiments, thecontact module is situated in the middle of the downhole tool drillstring, such that the contact module includes proximal and distal endsconfigured to be connected to other modules in the downhole tool drillstring. In other embodiments, the contact module can be situated at thedistal end of the downhole tool drill string. In each of theembodiments, the contact module maintains mechanical integrity in thedownhole tool drill string while the downhole tool drill string islifted or raised and lowered in the well borehole. In variousembodiments, the external electrical contacts are integrated into thedrilling system, rather than into a distinct contact module. In such anembodiment, for example, the external electrical contacts are integratedinto any portion, component, or aspect of the MWD drill string or otherdownhole device.

Throughout this disclosure, a spearpoint contact module is described asan example of a contact module of the disclosure. While in thisdisclosure, the spearpoint contact module is used as one example of acontact module, the components, ideas, and concepts illustrated and/ordescribed in relation to the spearpoint contact module can also be andare used in other contact modules, such as contact modules situated inthe middle of the downhole tool drill string or other contact modulessituated at the proximal or distal end of the downhole tool drillstring.

Communicating data between the downhole processor and a surfaceprocessor may be performed using various types of telemetry. Forexample, mud pulse telemetry and/or electromagnetic (EM) telemetry. EMtelemetry may be capable of transmitting data at a faster rate than mudpulse telemetry. However, EM telemetry is not as robust as mud pulsetelemetry and EM telemetry may fail in certain situations (e.g., deepwells or highly conductive wells). Accordingly, some of the disclosedembodiments provide techniques that leverage the benefits of both formsof telemetry to provide enhanced communications. For example, in someembodiments, a downhole processor may operate in mud pulse mode bydefault to ensure a connection is maintained with the surface processor.The downhole processor may perform a handshake by transmitting a messagevia an EM mode, and if the downhole processor receives a correspondingEM response from the surface processor, the downhole processor mayswitch from a mud pulse mode to the EM mode to leverage the faster datatransmission rate. If the EM mode disconnects or the downhole processordetermines a certain fluid flow is below a threshold level, the downholeprocessor may switch back to operating in mud pulse mode. Accordingly,technical benefits of the disclosure may include ensuring connectivityis maintained throughout the process and improving data transmissionrates when available.

FIG. 1 is a diagram illustrating a system 10 including a contact module12 configured for communicating with a downhole device 14, according toembodiments of the disclosure. As shown in FIG. 1, the contact module 12is a spearpoint. The spearpoint 12 is mechanically and electricallycoupled to the device 14 and includes at least one external contact 16for communicating with the device 14 through the at least one externalcontact 16. The spearpoint 12 is physically connected to the device 14and configured for lifting at least the spearpoint 12 and the device 14.The spearpoint 12 is configured to be mechanically strong enough tomaintain mechanical integrity while lifting the spearpoint 12 and thedevice 14.

In embodiments, the device 14 gathers data downhole and stores the datafor later retrieval. In embodiments, the device 14 is an MWD tool. Inother embodiments, the device 14 is one or more other suitable devices,including devices that gather data downhole.

Examples described herein are described in relation to a spearpoint 12.However, in some embodiments, the mechanical and electrical aspects ofthe spearpoint 12, including the electrical contact configurations ofthe spearpoint 12, described herein, can be used in other applicationsand on other items. In some embodiments, the mechanical and electricalaspects of the spearpoint 12, including the electrical contactconfigurations of the spearpoint 12, described herein, are or can beused in other contact modules, such as contact modules situated in themiddle of the downhole tool drill string or other contact modulessituated at the proximal or distal end of the downhole tool drillstring.

The system 10 includes a borehole drill string 22 and a rig 24 fordrilling a well borehole 26 through earth 28 and into a formation 30.After the well borehole 26 has been drilled, fluids such as water, oil,and gas can be extracted from the formation 30. In some embodiments, therig 24 is situated on a platform that is on or above water for drillinginto the ocean floor.

In one example, the rig 24 includes a derrick 32, a derrick floor 34, arotary table 36, and the drill string 22. The drill string 22 includes adrill pipe 38 and a drilling assembly 40 attached to the distal end ofthe drill pipe 38 at the distal end of the drill string 22.

The drilling assembly 40 includes a drill bit 42 at the bottom of thedrilling assembly 40 for drilling the well borehole 26.

A fluidic medium, such as drilling mud 44, is used by the system fordrilling the well borehole 26. The fluidic medium circulates through thedrill string 22 and back to the fluidic medium source, which is usuallyat the surface. In embodiments, drilling mud 44 is drawn from a mud pit46 and circulated by a mud pump 48 through a mud supply line 50 and intoa swivel 52. The drilling mud 44 flows down through an axial centralbore in the drill string 22 and through jets (not shown) in the lowerface of the drill bit 42. Borehole fluid 54, which contains drilling mud44, formation cuttings, and formation fluid, flows back up through theannular space between the outer surface of the drill string 22 and theinner surface of the well borehole 26 to be returned to the mud pit 46through a mud return line 56. A filter (not shown) can be used toseparate formation cuttings from the drilling mud 44 before the drillingmud 44 is returned to the mud pit 46. In some embodiments, the drillstring 22 has a downhole drill motor 58, such as a mud motor, forrotating the drill bit 42.

In embodiments, the system 10 includes a first module 60 and a secondmodule 62 that are configured to communicate with one another, such aswith the first module 60 situated downhole in the well borehole 26 andthe second module 62 at the surface. In embodiments, the system 10includes the first module 60 situated at the distal end of the drillpipe 38 and the drill string 22, and the second module 62 attached tothe drill rig 24 at the proximal end of the drill string 22 at thesurface. In embodiments, the first module 60 is configured tocommunicate with the device 14, such as through a wired connection orwirelessly.

The first module 60 includes a downhole processor 64 and a pulser 66,such as a mud pulse valve, communicatively coupled, such as by wire orwirelessly, to the downhole processor 64. The pulser 66 is configured toprovide a pressure pulse in the fluidic medium in the drill string 22,such as the drilling mud 44. The second module 62 includes an upholeprocessor 70 and a pressure sensor 72 communicatively coupled, such asby wire 74 or wirelessly, to the uphole processor 70.

In some embodiments, the pressure pulse is an acoustic signal and thepulser 66 is configured to provide an acoustic signal that istransmitted to the surface through one or more transmission pathways.These pathways can include the fluidic medium in the drill string 22,the material such as metal that the pipe is made of, and one or moreother separate pipes or pieces of the drill string 22, where theacoustic signal can be transmitted through passageways of the separatepipes or through the material of the separate pipes or pieces of thedrill string 22. In embodiments, the second module 62 includes theuphole processor 70 and an acoustic signal sensor configured to receivethe acoustic signal and communicatively coupled, such as by wire orwirelessly, to the uphole processor 70.

Each of the downhole processor 64 and the uphole processor 70 is acomputing machine that includes memory that stores executable code thatcan be executed by the computing machine to perform processes andfunctions of the system 10. In embodiments, the computing machine is oneor more of a computer, a microprocessor, and a micro-controller, or thecomputing machine includes multiples of a computer, a microprocessor,and/or a micro-controller. In embodiments, the memory is one or more ofvolatile memory, such as random access memory (RAM), and non-volatilememory, such as flash memory, battery-backed RAM, read only memory(ROM), varieties of programmable read only memory (PROM), and diskstorage. Also, in embodiments, each of the first module 60 and thesecond module 62 includes one or more power supplies for providing powerto the module.

As illustrated in FIG. 1, the spearpoint contact module 12 is physicallyconnected to the device 14. The spearpoint 12 is made from material thatis strong enough for lifting the spearpoint 12 and the device 14 fromthe well borehole 26 and for otherwise lifting the spearpoint 12 and thedevice 14. In some embodiments, the spearpoint 12 is made from one ormore pieces of metal. In some embodiments, the spearpoint 12 is madefrom one or more pieces of steel.

The spearpoint 12 includes the at least one external contact 16 that iselectrically coupled to the device 14 for communicating with the device14 through the at least one external contact 16. In embodiments, the atleast one external contact 16 is electrically coupled to the device 14through one or more wires. In embodiments, the at least one externalcontact 16 is configured to provide one or more of CAN buscommunications, RS232 communications, and RS485 communications betweenthe device 14 and a surface processor.

FIG. 2A is a diagram illustrating the spearpoint contact module 12engaged by an over shot tool 80 for lifting the spearpoint 12 and thedevice 14, according to embodiments of the disclosure. The spearpoint 12is configured to be manipulated by a tool, such as a soft release tool,to lower the spearpoint 12 on a cable into the well borehole 26 and torelease the spearpoint 22 when the spearpoint 12 has been placed intoposition. The over shot tool 80 is used to engage the spearpoint 12 toretrieve the spearpoint 12 from the well borehole 26 and bring thespearpoint 12 to the surface. In embodiments, the over shot tool 80 isused for lifting the spearpoint 12 and the device 14 from the wellborehole 26 and/or for otherwise lifting the spearpoint 12 and thedevice 14.

The spearpoint 12 includes a distal end 82 and a proximal end 84. Thespearpoint 12 includes an end shaft 86 at the distal end 82 and a latchrod 88 and nose 90 at the proximal end 84. The end shaft 86 isconfigured to be physically connected to the device 14, and the latchrod 88 and the nose 90 are configured to be engaged by the over-shottool 80 for lifting the spearpoint 12 and the device 14. In embodiments,the end shaft 86 is configured to be threaded onto or into the device14. In embodiments, the device 14 is an MWD tool and the end shaft 86 isconfigured to be threaded onto or into the MWD tool.

The spearpoint 12 further includes a contact shaft 92 situated betweenthe end shaft 86 and the latch rod 88. The contact shaft 92 includes theat least one external contact 16 that is configured to be electricallycoupled to the device 14. In this example, the contact shaft 92 includestwo annular ring external contacts 16 a and 16 b that are eachconfigured to be electrically coupled to the device 14 for communicatingwith the device 14 through the external contacts 16 a and 16 b. Theseexternal contacts 16 a and 16 b are insulated from each other and fromother parts of the spearpoint 12 by insulating material 94. In someembodiments, the external contacts 16 a and 16 b are configured to beelectrically coupled to the device 14 through wires 96 a and 96 b,respectively. In other embodiments, the spearpoint 12 can include oneexternal contact or more than two external contacts.

FIG. 2B is a diagram illustrating a contact module 12′ that isconfigured to be situated in the middle of a downhole tool drill stringand for communicating with the downhole device 14, according toembodiments of the disclosure. The contact module 12′ is another exampleof a contact module of the present disclosure.

The contact module 12′ includes a downhole or distal end 98 a and anuphole or proximal end 98 b. The distal end 98 a is configured to beconnected, such as by threads, onto or into the downhole device 14 oronto or into another module of the downhole tool drill string. Theproximal end 98 b is configured to be connected, such as by threads,onto or into another module of the downhole drill string, such as aretrieval tool. In embodiments, the device 14 is an MWD tool.

The contact module 12′ includes a contact shaft 92 situated between thedistal end 98 a and the proximal end 98 b. The contact shaft 92 includesthe at least one external contact 16 that is configured to beelectrically coupled to the device 14. In this example, the contactshaft 92 includes two annular ring external contacts 16 a and 16 b thatare each configured to be electrically coupled to the device 14 forcommunicating with the device 14 through the external contacts 16 a and16 b. These external contacts 16 a and 16 b are insulated from eachother and from other parts of the contact module 12′ by insulatingmaterial 94. In some embodiments, the external contacts 16 a and 16 bare configured to be electrically coupled to the device 14 through wires96 a and 96 b, respectively. In some embodiments, the contact module 12′can include one external contact or more than two external contacts.

FIG. 3 is a diagram schematically illustrating a surface processor 100configured to communicate with a downhole device 14 through a surfaceconnector 102 and a contact module 12, such as a spearpoint or a contactmodule 12′, according to embodiments of the disclosure. The proximal end84 of the spearpoint 12 is inserted into the surface connector 102 andthe distal end 82 of the spearpoint 12 is physically connected, such asby threads, to the proximal end 104 of the device 14. In drillingoperations, the proximal end 84 of the spearpoint 12 is situated upholeand the distal end 106 of the device 14 is situated downhole. In otherembodiments, the surface connector 102 is configured to engage adifferent contact module, such as contact module 12′, for communicatingwith the device 14 through the surface connector 102 and the contactmodule 12′.

The surface processor 100 is a computing machine that includes memorythat stores executable code that can be executed by the computingmachine to perform the processes and functions of the surface processor100. In embodiments, the surface processor 100 includes a display 108and input/output devices 110, such as a keyboard and mouse. Inembodiments, the computing machine is one or more of a computer, amicroprocessor, and a micro-controller, or the computing machineincludes multiples of a computer, a microprocessor, and/or amicro-controller. In embodiments, the memory in the surface processor100 includes one or more of volatile memory, such as RAM, andnon-volatile memory, such as flash memory, battery-backed RAM, ROM,varieties of PROM, and disk storage. Also, in embodiments, the surfaceprocessor 100 includes one or more power supplies for providing power tothe surface processor 100.

The surface connector 102 is configured to receive the spearpoint 12 andincludes at least one surface electrical contact 112 that iselectrically coupled to the surface processor 100 and configured to makeelectrical contact with the at least one external contact 16 on thespearpoint 12. In embodiments, the surface connector 102 includesmultiple surface electrical contacts 112 configured to make electricalcontact with corresponding external contacts 16 on the contact module,such as the spearpoint contact module 12 or the contact module 12′.

As illustrated in FIG. 3, the surface connector 102 includes two surfaceelectrical contacts 112 a and 112 b that are insulated from each otherand electrically coupled to the surface processor 100 by communicationspaths 114 a and 114 b, such as wires. Also, the spearpoint 12 includestwo external contacts 16 a and 16 b that are electrically coupled to thedevice 14 through communications paths 96 a and 96 b, such as wires. Thetwo surface electrical contacts 112 a and 112 b make electrical contactwith the two external contacts 16 a and 16 b of the spearpoint 12, wheresurface electrical contact 112 a makes electrical contact with theexternal contact 16 a and surface electrical contact 112 b makeselectrical contact with the external contact 16 b. Thus, the surfaceprocessor 100 is communicatively coupled to the device 14 throughcommunications paths 114 a and 114 b, the two surface electricalcontacts 112 a and 112 b, the two external contacts 16 a and 16 b, andcommunications paths 96 a and 96 b.

Also, in embodiments, the surface connector 102 includes one or morewiper seals 116 configured to clean the two external contacts 16 a and16 b (or the at least one external contact 16) on the spearpoint 12 asthe surface connector 102 is coupled onto the spearpoint 12. This wipesthe two external contacts 16 a and 16 b clean prior to making electricalcontact with the surface electrical contacts 112 a and 112 b of thesurface connector 102.

In embodiments, the device 14 is an MWD tool 120 enclosed in one or morebarrels of an MWD system string. The MWD tool 120 includes one or moreof a transmitter 122, a gamma ray sensor 124, a controller 126 such as adirectional controller, a sensor system 128 including one or more othersensors, and at least one battery 130. In embodiments, the transmitter122 includes at least one of a pulser, a positive mud pulser, a negativemud pulser, an acoustic transceiver, an electromagnetic transceiver, anda piezo transceiver. In embodiments, the gamma ray sensor 124 includesat least one of a proportional gamma ray sensor, a spectral gamma raysensor, a bulk gamma ray sensor, a resistivity sensor, and a neutrondensity sensor. In embodiments, the controller 126 includes at least oneof a processor, power supplies, and orientation sensors.

The MWD tool 120 is configured to acquire downhole data and eithertransmit the value to the surface or store the downhole data for laterretrieval once on the surface. The controller 126 includes a processorthat is a computing machine that includes memory that stores executablecode that can be executed by the computing machine to perform theprocesses and functions of the MWD tool 120. In embodiments, thecomputing machine is one or more of a computer, a microprocessor, and amicro-controller, or the computing machine includes multiples of acomputer, a microprocessor, and/or a micro-controller. In embodiments,the memory is one or more of volatile memory, such as RAM, andnon-volatile memory, such as flash memory, battery-backed RAM, ROM,varieties of PROM, and disk storage. Also, in embodiments, thecontroller 126 includes one or more power supplies for providing powerto the MWD tool 120. In embodiments, the MWD tool 120 is configured totransmit at least some of the acquired data to the surface via thetransmitter 122 when the MWD tool 120 is downhole.

In some embodiments, the MWD tool 120 is equipped with large, commercialgrade accelerometers, such as aerospace inertial grade accelerometers,that are highly accurate sensors. Also, in some embodiments, the MWDtool 120 is equipped with fluxgate magnetometers, which are known fortheir high sensitivity. In some embodiments, the MWD tool 120 is anintegrated tool configured to use micro electro-mechanical system (MEMS)accelerometers and solid-state magnetometers, which require less powerand fewer voltage rails than the commercial grade sensors. Also, theMEMS accelerometers and solid-state magnetometers provide for a morecompact MWD tool 120 that can be more reliable, durable, and consumeless power while still providing the same level of accuracy.

In operation, the surface connector 102 is coupled to the spearpoint 12,such as by sliding the surface connector 102 onto the spearpoint 12. Insome embodiments, the surface connector 102 includes the one or morewiper seals 116 that clean the two external contacts 16 a and 16 b onthe spearpoint 12 as the surface connector 102 is slid onto thespearpoint 12. This wipes the two external contacts 16 a and 16 b cleanprior to making electrical contact with the surface electrical contacts112 a and 112 b of the surface connector 102.

In some embodiments, after cleaning the two external contacts 16 a and16 b by hand or with the one or more wiper seals 116, the two externalcontacts 16 a and 16 b are energized or activated for communicationswith the device 14.

With the surface processor 100 communicatively coupled to the device 14through the two surface electrical contacts 112 a and 112 b and the twoexternal contacts 16 a and 16 b of the spearpoint 12, the surfaceprocessor 100 communicates with the device 14 through the surfaceconnector 102 and the spearpoint 12. In some embodiments, communicatingwith the device 14 includes one or more of CAN bus communications, RS232communications, and RS485 communications.

FIG. 4 is a diagram illustrating a spearpoint contact module 200connected to a device 202 and a surface connector 204 configured to becoupled onto the spearpoint 200, according to embodiments of thedisclosure. In some embodiments, the spearpoint 200 is like thespearpoint 12. In some embodiments, the device 202 is like the device14. In some embodiments, the device 202 is like the MWD tool 120. Insome embodiments, the surface connector 204 is like the surfaceconnector 102.

The spearpoint 200 includes an end shaft 206 at a distal end 208 and alatch rod 210 and nose 212 at a proximal end 214, where in drillingoperations, the distal end 208 is situated downhole and the proximal end214 is situated uphole. The end shaft 206 is physically connected to thedevice 202, and the latch rod 210 and the nose 212 are configured to beengaged by an over-shot tool for lifting the spearpoint 200 and thedevice 202. In embodiments, the end shaft 206 is configured to bethreaded onto or into the device 202. In embodiments, the device 202includes the MWD tool 120 and the end shaft 206 is configured to bethreaded onto or into the MWD tool 120.

The spearpoint 200 includes a contact shaft 216 situated between the endshaft 206 and the latch rod 210. The contact shaft 216 includes twoexternal electrical contacts 218 a and 218 b that are each configured tobe electrically coupled to the device 202 for communicating with thedevice 202 through the contacts 218 a and 218 b. In embodiments, one ormore of the contacts 218 a and 218 b is an annular ring electricalcontact. In embodiments, the contacts 218 a and 218 b are electricallycoupled to the device 202 through wires. In embodiments, the spearpoint200 can include one external electrical contact or more than twoexternal electrical contacts.

The contacts 218 a and 218 b are insulated from each other and fromother parts of the spearpoint 200 by insulating material. The contacts218 a and 218 b are insulated from each other by insulator 220 a that issituated between the contacts 218 a and 218 b. Also, contact 218 a isinsulated from the end shaft 206 at the distal end 208 by insulator 220b and contact 218 b is insulated from the latch rod 210 and the proximalend 214 by insulator 220 c. In embodiments, one or more of theinsulators 220 a, 220 b, and 220 c is an annular ring insulator. Inembodiments, one or more of the insulators 220 a, 220 b, and 220 c ismade from one or more of ceramic, rubber, and plastic.

The surface connector 204 is configured to receive the proximal end 214of the spearpoint 200, including the latch rod 210 and the nose 212, andthe contact shaft 216 of the spearpoint 200. The surface connector 204includes two or more surface electrical contacts (not shown in FIG. 4)that are electrically coupled to a surface processor, such as surfaceprocessor 100, by communications path 222. These two or more surfaceelectrical contacts are configured to make electrical contact with thespearpoint contacts 218 a and 218 b when the spearpoint 200 is insertedinto the surface connector 204. Thus, the surface processor such assurface processor 100 is communicatively coupled to the device 202through the two or more surface electrical contacts of the surfaceconnector 204 and the two spearpoint contacts 218 a and 218 b of thespearpoint 200.

Also, in embodiments, the surface connector 204 includes one or morewiper seals that clean the spearpoint contacts 218 a and 218 b as thesurface connector 204 is coupled onto the spearpoint 200. This wipes thespearpoint contacts 218 a and 218 b clean prior to making electricalcontact with the surface electrical contacts of the surface connector204.

FIG. 5 is a diagram illustrating the spearpoint 200 including at leastportions of the end shaft 206, the contact shaft 216, and the latch rod210, according to embodiments of the disclosure, and FIG. 6 is anexploded view diagram of the spearpoint 200 shown in FIG. 5, accordingto embodiments of the disclosure. As described above, the spearpointcontact module 12 is one example of a contact module of the disclosure,such that the components, ideas, and concepts illustrated and/ordescribed in relation to the spearpoint contact module 12 can also beused in other contact modules, such as contact module 12′ configured tobe situated in the middle of the downhole tool drill string or othercontact modules situated at the proximal or distal end of the downholetool drill string.

Referencing FIGS. 5 and 6, the end shaft 206 includes a first member 230that includes a central shaft 232, and the latch rod 210 includes asecond member 234. The central shaft 232 of the first member 230 extendsthrough the external electrical contacts 218 a and 218 b and insulators220 a-220 c of the contact shaft 216 and into the second member 234. Thecentral shaft 232 is a tensile load bearing member. The central shaft232 engages the second member 234, such that the first member 230 andthe second member 234 are secured together to maintain mechanicalintegrity of the spearpoint 200. In embodiments, the central shaft 232and the second member 234 include threads, such that the central shaft232 and the second member 234 are threaded together. In embodiments, thefirst member 230 is made from metal, such as steel. In embodiments, thesecond member 234 is made from metal, such as steel. In embodiments, theelectrical contacts 218 a and 218 b are made from metal.

The contact shaft 216 is situated between the end shaft 206 and thelatch rod 210 and includes the two external electrical contacts 218 aand 218 b and the three insulators 220 a-220 c. The contacts 218 a and218 b are insulated from each other and from other parts of thespearpoint 200 by the insulators 220 a-220 c. The contacts 218 a and 218b are insulated from each other by insulator 220 a that is situatedbetween the contacts 218 a and 218 b. Also, contact 218 a is insulatedfrom the end shaft 206 by insulator 220 b, and contact 218 b isinsulated from the latch rod 210 and the second member 234 by insulator220 c. In embodiments, one or more of the insulators 220 a, 220 b, and220 c is made from one or more of ceramic, rubber, and plastic.

The contact shaft 216 also includes six o-ring seals 236 a-236 f thatare situated between the contacts 218 a and 218 b and the insulators 220a-220 c, and between insulator 220 b and the first member 230, andinsulator 220 c and the second member 234. The o-rings 236 a-236 f areconfigured to resist or prevent fluid from invading through the contactshaft 216 and to the central shaft 232. The contacts 218 a and 218 b,insulators 220 a, 220 b, and 220 c, and o-rings 236 a-236 f provide apressure seal for the spearpoint contact module 12, such that thespearpoint 12 is pressure sealed to prevent drilling fluid and otherfluids from invading the contact module. This prevents the drillingfluid and other fluids from interfering with communications between thespearpoint 12 and the downhole device 14, such as by preventing shortcircuits. In embodiments, one or more of the o-rings 236 a-236 f is madefrom one or more of ceramic, rubber, and plastic.

Each of the contacts 218 a and 218 b is an annular ring electricalcontact that is slid over or onto the central shaft 232, and each of thethree insulators 220 a-220 c is an annular ring insulator that is slidover or onto the central shaft 232. Also, each of the o-rings 236 a-236f is slid over or onto the central shaft 232.

Electrical contact 218 a is further insulated from the central shaft 232by semicircular insulators 238 a and 238 b inserted between theelectrical contact 218 a and the central shaft 232, and electricalcontact 218 b is further insulated from the central shaft 232 bysemicircular insulators 240 a and 240 b inserted between the electricalcontact 218 b and the central shaft 232. In embodiments, thesemicircular insulators 238 a and 238 b are made from one or more ofceramic, rubber, and plastic. In embodiments, the semicircularinsulators 240 a and 240 b are made from one or more of ceramic, rubber,and plastic.

The external electrical contacts 218 a and 218 b are electricallycoupled to communications path 242 by electrical connectors 244 and 246,respectively. Electrical contact 218 a is electrically coupled toconnector 244, which is attached to the electrical contact 218 a byscrew 248. Electrical contact 218 b is electrically coupled to connector246, which is attached to the electrical contact 218 b by screw 250.Each of the electrical connectors 244 and 246 is further electricallycoupled to the communications path 242. In embodiments, each of theelectrical connectors 244 and 246 is electrically coupled to anindividual wire that is further electrically coupled to the device 202.In embodiments, the communications path 242 is connected to the firstmember 230, such as by a strain relief 252.

The central shaft 232 includes a first slot 254 that provides an openingor path for the connections of the connectors 244 and 246 to thecommunications path 242. The central shaft 232 includes a second slot256 that is configured to receive a keying element or key 258. Where, inembodiments, the electrical contacts 218 a and 218 b are keyed such thatthe key 258 prevents the electrical contacts 218 a and 218 b and thecentral shaft 232 from spinning in relation to one another, whichprevents twisting off the connections between the connectors 244 and 246and the communications path 242. Thus, the first member 230 and theelectrical contacts 218 a and 218 b are keyed to prevent rotation of thefirst member 230 in relation to the electrical contacts 218 a and 218 b.In embodiments, the key 258 includes one or more of nylon, ceramic,rubber, and plastic.

FIG. 7 is a diagram illustrating the spearpoint 200 and the device 202and a cross-sectional view of the surface connector 204, according toembodiments of the disclosure. The spearpoint 200 is securely connectedto the device 202, such as by threads, and not inserted into or coupledto the surface connector 204 in FIG. 7. FIG. 8 is a diagram illustratingthe spearpoint 200 inserted into the surface connector 204 and/orcoupled to the surface connector 204, according to embodiments of thedisclosure.

Referencing FIGS. 7 and 8, the spearpoint 200 includes the end shaft206, the contact shaft 216, and the latch rod 210 and nose 212. The endshaft 206 is physically connected to the device 202, and the contactshaft 216 includes the two external electrical contacts 218 a and 218 bthat are each configured to be electrically coupled to the device 202for communicating with the device 202 through the contacts 218 a and 218b. In embodiments, the end shaft 206 is threaded onto or into the device202. In embodiments, the device 202 includes the MWD tool 120 and theend shaft 206 is threaded onto or into the MWD tool 120. In otherembodiments, the spearpoint 200 can include one external electricalcontact or more than two external electrical contacts.

The contacts 218 a and 218 b are insulated from each other by insulator220 a that is situated between the contacts 218 a and 218 b. Also,contact 218 a is insulated from the end shaft 206 at the distal end 208by insulator 220 b, and contact 218 b is insulated from the latch rod210 and the proximal end 214 by insulator 220 c.

The surface connector 204 includes a tubular passage 262 configured toreceive the latch rod 210, the nose 212, and the contact shaft 216 ofthe spearpoint 200. The passage 262 receives the nose 212 of thespearpoint 200 at a proximal end 264 of the passage 262, followed by thelatch rod 210 and then the contact shaft 216. The surface connector 204has angled recess portions 266 at a distal end 268 of the passage 262.These angled recess portions 266 rest on angled portions 274 of the endshaft 206 of the spearpoint 200 after or when the spearpoint 200 isinserted into the surface connector 204. In other embodiments, thesurface connector 204 can be configured to engage a different contactmodule, such as contact module 12′.

In the present example, the surface connector 204 includes two surfaceelectrical contacts 268 a and 268 b that are each electrically coupledto the surface processor, such as surface processor 100, bycommunications path 222. The surface electrical contacts 268 a and 268 bare configured to make electrical contact with the spearpoint contacts218 a and 218 b when the spearpoint 200 is inserted into the surfaceconnector 204. In embodiments, each of the surface electrical contacts268 a and 268 b is an annular ring electrical contact. In embodiments,each of the surface electrical contacts 268 a and 268 b is sized to makeelectrical contact with the spearpoint contacts 218 a and 218 b.

The surface connector 204 further includes three spacers 270 a-270 cthat are beside the surface electrical contacts 268 a and 268 b. Spacer270 a is situated between the surface electrical contacts 268 a and 268b, spacer 270 b is situated distal the surface electrical contact 268 a,and spacer 270 c is situated proximal the surface electrical contact 268b. In some embodiments, one or more of the spacers 270 a-270 c is aninsulator, such as a ceramic, rubber, or plastic insulator. In someembodiments one or more of the spacers 270 a-270 c is a wiper sealconfigured to wipe the electrical contacts 218 a and 218 b clean.

In embodiments, the surface connector 204 includes one or more wiperseals 272 that clean the spearpoint contacts 218 a and 218 b as thesurface connector 204 is coupled onto the spearpoint 200. This wipes thespearpoint contacts 218 a and 218 b clean prior to making electricalcontact with the surface electrical contacts 268 a and 268 b of thesurface connector 204.

In operation, the spearpoint 200 is inserted into the surface connector204, such that the spearpoint contacts 218 a and 218 b make electricalcontact with the surface electrical contacts 268 a and 268 b of thesurface connector 204. Spearpoint contact 218 a makes electrical contactwith surface electrical contact 268 a, and spearpoint contact 218 bmakes electrical contact with surface electrical contact 268 b. Thiselectrically and communicatively couples the surface processor, such assurface processor 100, to the device 202 through the surface electricalcontacts 268 a and 268 b and the spearpoint contacts 218 a and 218 b.The surface processor communicates with the device 202, such as byprogramming the device 202 or downloading data from the device 202. Inembodiments, the surface processor and the device 202 communicate usingone or more of single line communications, CAN communications, RS232communications, and RS485 communications.

FIG. 9 is a flow chart diagram illustrating a method of communicatingwith a device 202, such as a drill string tool, through a contactmodule, such as spearpoint contact module 200, according to embodimentsof the disclosure. In other example embodiments, the mechanical andelectrical aspects of the spearpoint 200, including the electricalcontact configurations of the spearpoint 200 described herein can beused in other contact modules, such as contact module 12′. In otherexample embodiments, the mechanical and electrical aspects of thespearpoint 200, including the electrical contact configurations of thespearpoint 200 described herein can be used in other applications and onother items, such as EM head and rotator connector (wet connect)applications.

To begin, at 300, the method includes inserting the spearpoint 200 intothe surface connector 204 at the surface without disconnecting thespearpoint 200 from the device 202.

With insertion, the spearpoint contacts 218 a and 218 b make electricalcontact with the surface electrical contacts 268 a and 268 b, such thatspearpoint contact 218 a makes electrical contact with surfaceelectrical contact 268 a, and spearpoint contact 218 b makes electricalcontact with surface electrical contact 268 b. The surface connector 204can be connected to the surface processor either before or after thespearpoint 200 is inserted into the surface connector 204.

This results in the surface processor being electrically andcommunicatively coupled to the device 202 through the surface electricalcontacts 268 a and 268 b and the spearpoint contacts 218 a and 218 b. Insome embodiments, inserting the spearpoint 200 into the surfaceconnector 204 wipes the spearpoint contacts 218 a and 218 b clean priorto making electrical contact with the surface electrical contacts 268 aand 268 b of the surface connector 204.

The surface processor then communicates with the device 202 byperforming at least one of programming or configuring the device 202, at302, and downloading data from the device 202, at 304. In embodiments,the surface processor and the device 202 communicate using one or moreof single line communications, CAN communications, RS232 communications,and RS485 communications.

At 306, the spearpoint 200 is decoupled or removed from the surfaceconnector 304, and then returned to normal surface.

FIG. 10 is a block diagram of various electronic components included inthe contact module 12. It should be noted that the electronic componentsdepicted are for explanatory purposes and fewer or additional electroniccomponents may be included in the contact module 12. It should also benoted that the contact module 12 may be the spearpoint contact module 12of FIG. 2A or the contact module 12′ of FIG. 2B. The contact module 12may be electrically connected and physically connected to the downholedevice 14 (e.g., via threads). Electrically connected may refer to aconnection by means of a conducting path or through a capacitor, and mayalso enable communication of data via the electrical connection.Accordingly, electrically connected may also mean the devices that areelectrically connected are also communicatively connected.

As depicted, the contact module 12 includes the contact shaft 92 with atleast one external contact 16 (e.g., 16 a and 16 b) that may beelectrically connected to at least one external contact 112 (e.g., 112 aand 112 b) of the surface connector 102. The electrical connectionbetween the external contacts 16 and 112 may enable communicating databetween the contact module 12 and the surface connector 102. Forexample, the electrical connection may enable the surface connector 102and the device 14 to communicate data through the contact module 12.

As depicted, the contact module 12 may include one or more electricalcomponents. Each electrical component may include one or more electricalsub-components. In some embodiments, the contact module 12 includes afirst component 1000 and a second component 1002. In some embodiments,the first component 1000 and the second component 1002 may each beimplemented using a separate circuit board (e.g., printed circuitboard). The circuit board(s) may include various integrated circuits. Insome embodiments, the first component 1000 and the second component 1002may be implemented on the same circuit board. For example, the firstcomponent 1000 and the second component 1002 may be implemented on thesame circuit board but may be isolated in different sections. In someembodiments, the first component 1000 and the second component 1002 mayeach be implemented on more than one circuit board. The circuit board orcircuit boards used to implement the first component 1000 and the secondcomponent 1002 may include one or more layers.

The first component 1000 may include the following sub-components: (i) atransceiver 1004 (also referred to as a “first data path” herein), (ii)a processor 1006, (iii) a transceiver 1008 (also referred to as a“second data path” herein), and/or (iv) a differential line transceiver1010. The transceiver 1005 may be electrically connected to theprocessor 1006 and the downhole device 14. The processor may beelectrically connected to the transceiver 1008, such that the processor1006 is electrically connected between both the transceivers 1004 and1008. The transceiver may be further electrically connected to thedifferential line transceiver 1010.

Each of the transceivers 1004 and 1008 may be capable of communicatingdata (e.g., receiving data and transmitting data). Each of thetransceivers 1004 and 1008 may be an independent bus implemented usingRS485, RS232, RS422, FlexRay, Controller Area Network (CAN), CANFlexible Data-Rate (CANFD), a differential line driver pair, or thelike. A differential line driver pair may refer to the type of bus usedto connect two devices. Differential signaling is a technique forelectrically transmitting information (data) using two complementarysignals. The technique may transmit the data as the same electricalsignal having a differential pair of signals, each on its own conductor.The pair of conductors may be wires or traces on a circuit board. Thedifferential line driver pair may include a driver and a receiver wherethe driver converts an input signal (e.g., single-ended) to adifferential signal and the receiver receives a differential signal. Thedriver may also buffer a received differential signal and/or transmitthe received differential signal. Differential signals may be used asthey are resistant to noise and capable of carrying high-bitrate signalsreliably.

Each of the transceivers 1004 and 1008 may be capable of communicatingdata using a communication protocol. The communication protocol mayinclude RS485, RS232, RS422, FlexRay, Controller Area Network (CAN), CANFlexible Data-Rate (CANFD), a differential line driver pair, or thelike.

In some embodiments, each of the transceivers 1004 and 1008 maycommunicate data using different communication protocols. For example,the transceiver 1004 may communicate data using CAN as its communicationprotocol and the transceiver 1008 may communicate data using CANFD asits communication protocol. In some embodiments, the transceivers 1004and 1008 may communicate data using the same communication protocol.

In some embodiments, the differential line transceiver 1008 may be acombination of the receiver and the driver described above. For example,the driver of the differential line transceiver 1008 may convert aninput signal to a line signal. In some embodiments, the driver maygenerate a differential signal with complementary (+, −) sides. Thedriver may convert a single-ended signal to a differential signal,buffer a differential signal, or both. The receiver of the differentialline transceiver 1008 may receive a differential signal (e.g., linesignal) and convert it to an original input signal. For example, thereceiver may function as a translator in either unidirectional orbidirectional. Further, the differential line transceiver 1008 may becapable of receiving an input signal (e.g., single-ended, differential,etc.) and transmitting the received signal, either after conversion toanother type of signal or as the same type of signal that was received.

Although not depicted, the first component 1000 may include a memory.For example, the memory may be main memory (e.g., read-only memory(ROM), flash memory, solid state drives (SSDs), dynamic random accessmemory (DRAM) such as synchronous DRAM (SDRAM)), a static memory (e.g.,flash memory, solid state drives (SSDs), static random access memory(SRAM)), and/or a data storage device, which communicate with each otherand the processor 1006 via a bus. The memory may store computerinstructions that implement any of the operations performed by theprocessor 1006 described herein.

The processor 1006 may be one or more general-purpose processing devicessuch as a microprocessor, central processing unit, or the like. Moreparticularly, the processor 1006 may be a complex instruction setcomputing (CISC) microprocessor, reduced instruction set computing(RISC) microprocessor, very long instruction word (VLIW) microprocessor,or a processor implementing other instruction sets or processorsimplementing a combination of instruction sets. The processor 1006 mayalso be one or more special-purpose processing devices such as anapplication specific integrated circuit (ASIC), a system on a chip, afield programmable gate array (FPGA), a digital signal processor (DSP),network processor, or the like. The processor 1006 is configured toexecute instructions for performing any of the operations and/or stepsdiscussed herein.

The processor 1006 may perform networking operations by selectivelyrouting data between the transceiver 1004 and the transceiver 1008. Forexample, the processor 1006 may route data received from the downholedevice 14 via the transceiver 1004 to the transceiver 1008 to bedelivered to the surface processor 100 (e.g., computing device externalto the contact module 12) via the surface connector 102. In someembodiments, the processor 1006 may route data received from the surfaceprocessor 100 via the transceiver 1008 to the transceiver 1004 to bedelivered to the downhole device 14.

In some embodiments, the processor 1006 may selectively route the databetween the transceiver 1004 and the transceiver 1008 by performingnetwork switching operations. In some embodiments, the network switchingoperations may include determining whether the data is valid.Determining whether the data is valid may include determining whetherthe received data includes an invalid address for a device (e.g.,downhole device 14, surface processor 100, etc.), a cyclic redundancycheck (CRC) failure, a data rate failure, a payload failure, a maliciouscontent identification, or some combination thereof, as describedfurther below.

In some embodiments, responsive to determining the data is valid, theprocessor 1006 may perform at least one of the following operations: (i)route the data received from the downhole device 14 to be delivered tothe surface processor 100 separate from the contact module 12 and thedownhole device 14, (ii) route the data received from the surfaceprocessor 100 to be delivered to the downhole device 14, or (iv) both.

In some embodiments, responsive to determining the data is invalid, theprocessor 1006 may perform at least one of the following operations: (i)filter out the data (e.g., ignore corrupt data), or (ii) correct thedata using an error-correcting code technique.

The second component 1002 may isolate the external contacts 16 from aninternal bus (e.g., at least transceiver 1014) electrically connectingthe contact module 12 to the downhole device 14. As such, the secondcomponent 1002 may be a terminator capable of preventing the downholedevice 14 from short circuiting. The second component 1002 may bedirectly or indirectly (e.g., via a screw 248 or an electrical connector244 shown in FIG. 5) electrically connected to the external contact 16(e.g., using a wire). The second component 1002 may be capable reducingsignal reflections (e.g., reduced interference associated with signalloss) and/or power losses.

The second component 1002 may include the following sub-components: (i)a differential line transceiver 1012, (ii) a transceiver 1014 (alsoreferred to as a “third data path” herein), and/or (iv) an electrostaticdischarge (ESD) protection component 1016. The transceiver 1016 may becapable of communicating data (e.g., receiving data and transmittingdata). The transceiver 1016 may be a bus implemented using RS485, RS232,RS422, FlexRay, Controller Area Network (CAN), CAN Flexible Data-Rate(CANFD), a differential line driver pair, or the like. The transceiver1014 may be capable of communicating data using a communicationprotocol. The communication protocol may include RS485, RS232, RS422,FlexRay, Controller Area Network (CAN), CAN Flexible Data-Rate (CANFD),a differential line driver pair, or the like. In some embodiments, thecommunication protocol used by the transceiver 1016 may be the same ordifferent from the communication protocol used by the transceiver 1004and/or 1008.

Electrostatic discharge may refer to the sudden flow of electricitybetween two electrically charged objects caused by contact, anelectrical short, or dielectric breakdown. The ESD protection component1016 may include galvanic isolation, optical isolation, and/or inductiveisolation.

The second component 1002 may be electrically coupled to the externalcontact 16 via the ESD protection component 1016. The ESD protectioncomponent 1016 may isolate the transceiver 1014 from the externalcontact 16. Accordingly, the ESD protection component 1106 may protectthe contact module 12 and/or the downhole device 14 when the externalcontacts 16 and 112 are in contact with each other and current flowsbetween the external contacts 16 and 112. The ESD protection component1106 may allow data to pass from the surface processor 100 to thedownhole device 14 and/or from the downhole device 14 to the surfaceprocessor 100 while protecting from ESD.

The differential line transceiver 1012 may include similar componentsand may perform similar operations as the differential line transceiver1010 described above. The transceiver 1014 may be electrically connectedin between the ESD protection component 1016 and the differential linetransceiver 1012. The differential line transceiver 1012 may beelectrically connected to the differential line transceiver 1010 of thefirst component 1000.

The transceiver 1014 may receive data sent from the surface processor1000 and transmit the data to the differential line transceiver 1012.The data sent from the surface processor 1000 may include any suitabledata, such as instructions for the downhole device 14 to program thedownhole device 14, to program the processor 1006, to perform certainmeasurements, to transmit data at certain frequency, to transmit data ata certain time, to transmit data at a certain periodicity, and the like.

The differential line transceiver 1012 may transmit the data receivedfrom the transceiver 1014 to the differential line transceiver 1010 ofthe first component 1000. The data may be transmitted to the transceiver1008, then to the processor 1006 (which may perform various operationsand/or processes on the data), then to the transceiver 1004, and then tothe downhole device 14.

When data (e.g., MWD measurement data) is transmitted from the downholedata 14, the data is first received by the transceiver 1004 of the firstcomponent 1000. The data is then transmitted to the processor 1006(which may perform various operations and/or processes on the data),then to the transceiver 1008, and then to the differential linetransceiver 1010. The data may be transmitted by the differential linetransceiver 1010 to the differential line transceiver 1012. The datareceived at the differential line transceiver 1012 may be transmitted tothe transceiver 1014, and then to the surface connector 100 through theESD protection component 1016 and the external contacts 16 and 112.

The data may include a target address of a device (e.g., either thedownhole device 14, the surface processor 100, or any suitable computingdevice), a source address of the device (e.g., either the downholedevice 14, the surface processor 100, or any suitable computing device)sending the data, measurements of characteristics of the formation,measurements of conditions downhole including the movement and locationof the drilling assembly contemporaneously with the drilling of thewell, or any suitable data. The data may be encrypted by the sendingdevice (e.g., the downhole device 14 or the surface processor 100) usingany suitable symmetric and/or asymmetric technique. Accordingly, theprocessor 1006 may perform any corresponding decryption technique todecrypt the encrypted data upon receipt. The processor 1006 may alsoperform encryption on the data.

FIG. 11 illustrates example operations of a method 1100 for operatingthe processor 1006 as a network switch according to certain embodimentsof this disclosure. The method 1100 is performed by processing logicthat may include hardware (circuitry, dedicated logic, etc.), software(such as is run on a general purpose computer system or a dedicatedmachine), firmware, or some combination thereof. The method 1100 and/oreach of their individual functions, routines, subroutines, or operationsmay be performed by one or more processors of a computing device (e.g.,the processor 1006 FIG. 10). In certain implementations, the method 1100may be performed by a single processing thread. Alternatively, themethod 1100 may be performed by two or more processing threads, eachthread implementing one or more individual functions, routines,subroutines, or operations of the methods.

For simplicity of explanation, the method 1100 is depicted and describedas a series of operations. However, operations in accordance with thisdisclosure can occur in various orders and/or concurrently, and withother operations not presented and described herein. For example, theoperations depicted in the method 1100 may occur in combination with anyother operation of any other method disclosed herein. Furthermore, notall illustrated operations may be required to implement the method 1100in accordance with the disclosed subject matter. In addition, thoseskilled in the art will understand and appreciate that the method 1100could alternatively be represented as a series of interrelated statesvia a state diagram or events.

At 1102, the processing 1006 may receive data from the downhole device14 through a first data path (e.g., transceiver 1004). The processor1006 and the first data path may be included in the first component 1002of the contact module 12. The first data path may be a bus and mayenable communicating data using a first communication protocol (e.g.,CAN, RS485, RS232, RS422, FlexRay, CANFD, or a differential line driverpair). The data may be any suitable data, such as MWD measurement datareceived from the downhole device 14. The data may be encrypted by thedownhole device 14.

In some embodiments, the processor 1006 may receive data from thesurface processor 100. The data may be any suitable data, such asinstructions that program the downhole device 14 to perform certainmeasurements, or programs the processor 1006 to perform certainoperations. For example, the instructions may instruct the downholedevice 14 to perform MWD measurements at a certain frequency, at acertain periodicity, at a certain time, etc. In some embodiments, theinstructions may instruct the downhole device 14 to perform measurementspertaining to the formation. In some embodiments, the instructions mayinstruct the downhole device 14 to perform measurements pertaining tothe position, orientation, and/or location of the drilling assemblywhile the well is being drilled.

At 1104, the processor 1006 may determine whether the data is valid andperform various network switching operations based on whether the datais valid. To determine whether the data is valid, the processor 1006 mayperform various analytical techniques on the data. In some embodiments,the processor 1006 may authenticate the data, validate the data, or thelike. If the data is encrypted, the processor 1006 may decrypt the datausing any suitable decryption technique. For example, if public-privatekey encryption is used, the processor 1006 may decrypt the data with aprivate key. The processor 1006 may perform a cyclic redundancy check(CRC). CRC is an error detection mechanism in which a special number isappended by the downhole device 14 and/or the surface processor 100 to ablock of data in order to detect any changes introduced duringtransmission or storage. The special number may be recalculated by theprocessor 1006 upon receipt and compared to the value originallytransmitted. If the values match, there is no error in the data. If thevalues do not match, then there may be an error in the data.

In some embodiments, if there is an error in the data, the processor1006 may perform (1108) one or more operations. One operation mayinclude attempting to correct the error. For example, the processor 1006may use an error correction code (ECC) for controlling errors in dataover unreliable or noisy communication channels. The data may be encodedwith redundant information in the form of an ECC that is calculatedusing an algorithm. The redundancy allows the processor 1006 to detecterror(s) that may occur anywhere in the data, and to correct the errorswithout the sender having to retransmit the data. An example of an ECCis to transmit each data bit a certain number of times, which may bereferred to as a repetition code. This may enable correcting an error inany of the data that is received by a “majority vote” by comparing therespective data bits together.

In some embodiments, if there is an error in the data, another operationperformed by the processor 1006 may include ignoring the data byfiltering out the data. In such a case, the processor 1006 may nottransmit the data further. The processor 1006 may request the data to beretransmitted from the downhole device 14 and/or the surface processor100.

Errors in data may occur for various reasons. For example, noisychannels of communication may cause the data bits to change, therebyintroducing an error. The data may be invalid if it includes an invalidtarget device address and/or an invalid source device address. The datamay be invalid if the CRC fails and/or ECC fails to correct a detectederror. The data may be invalid if there is a data rate failure. Forexample, if data is not being received, transmitted, and/or processed ata certain data rate, then the data may be deemed invalid. The data maybe invalid if there is a payload failure. For example, if not all datain a payload is received within a certain threshold period of time, thenthe data may be deemed invalid. In some embodiments, if portions of thepayload arrive out of order, then the data may be deemed invalid. Thedata may be invalid if there is malicious content that is identified.For example, malicious content may include any type of suspicious data(e.g., unknown device address, unexpected measurements, etc.).

If the data is valid, the processor 1006 may transmit (1106) the data toa computing device (e.g., surface processor 100) external to the contactmodule 12 through a second data path (e.g., transceiver 1008). Thesecond data path may be a bus and may use a second communicationprotocol (e.g., CAN, RS485, RS232, RS422, FlexRay, CANFD, or adifferential line driver pair). In some embodiments, the first andsecond communication protocols may be the same or different. Forexample, the first communication path may be CAN and the secondcommunication path may be CANFD.

In some embodiments, the processor 1006 may receive data from the seconddata path 1008 that is sent by the surface processor 100. The processor1006 may perform various operations on the data and transmit the data tothe first data path 1004 to be delivered to the downhole device 14.

In some embodiments, the processor 1006 may encrypt the data using anysuitable encryption technique. For example, the processor 1006 may usesymmetric encryption with a single key to encrypt the data. The key maybe shared with the downhole device 14 and/or the surface processor 100.Asymmetric encryption (public key cryptography) may use two separatekeys, one is public and shared with the downhole device 14 and thesurface processor 100, and the other key is private. The public key maybe used to encrypt the data and the private key is used to decrypt theencrypted data.

In some embodiments, the processor 1006 may decrypt data received fromthe downhole device 14 or the surface processor 100 to generatedecrypted data. The processor 1006 may analyze the decrypted data todetermine whether the data is valid. In some embodiments, the processor1006 may transmit the decrypted data to a target device (e.g., thedownhole device 14 or the surface processor 100). In some embodiments,prior to transmitting the decrypted data, the processor 1006 mayre-encrypt the data to generate encrypted data. The processor 1006 maytransmit the encrypted data to a target device (e.g., the downholedevice 14 or the surface processor 100).

FIG. 12 illustrates example operations of a method 1200 for correctingdata received from the downhole device 14 or the surface processor 100that includes errors according to certain embodiments of thisdisclosure. Method 1200 includes operations performed by processors of acomputing device (e.g., the processor 1006 of FIG. 10). In someembodiments, one or more operations of the method 1200 are implementedin computer instructions that are stored on a memory device and executedby a processing device. The method 1200 may be performed in the same ora similar manner as described above in regards to method 1100. Theoperations of the method 1200 may be performed in some combination withany of the operations of any of the methods described herein.

The processor 1006 may receive data from the downhole device 14 or thesurface processor 100 and determine the data is invalid. In response todetermining the data is invalid, the processor 1006 may performoperations 1202, 1204, and 1206. At 1202, the processor 1006 may performerror correction on the data to generate corrected data. The errorcorrection may be performed using an ECC as described above or anysuitable error correction technique.

At 1204, the processor 1006 may determine whether the corrected data isvalid. The processor 1006 may determine whether the corrected data isvalid using a similar technique as was used to determine whether theoriginal data that was received was valid.

At 1206, responsive to determining the corrected data is valid, theprocessor 1006 may transmit the corrected data to the computing device(e.g., surface processor 100) external to the contact module 12 throughthe second data path.

FIG. 13A is a block diagram of various electronic components included inan electronic control module 15, according to embodiments of thedisclosure. As depicted, the contact module 12 may be electrically andcommunicatively coupled with the electronic module 15. The contactmodule 12 and the electronic control module 15 may be electrically andcommunicatively coupled with the downhole device 14. The contact module12 may include a transceiver 1301 that is configured to communicate datawith the surface processor 100 when the downhole device 14 is at thesurface (e.g., when external contacts of the contact module 12 areengaged with a surface connector 102 (not shown)).

The electronic control module 15 may include various electroniccomponents, such as the downhole processor 1300, a memory 1302, a sensor1304, an electromagnetic (EM) transceiver 1310, and/or a mud pulse (MP)transceiver 1311. As depicted in FIG. 13A, the EM transceiver 1310 andthe MP transceiver 1311 are separate and distinct components in theelectronic control module 15. The downhole processor 1300 may beconfigured to transmit messages via a wireless protocol in varioustransmission modes. For example, the downhole processor 1300 may commandthe MP transceiver 1311 to transmit mud pulse messages when theoperating in a mud pulse mode. The downhole processor 1300 may commandthe EM transceiver 1310 to transmit electromagnetic (EM) messages whenoperating in EM mode. The downhole processor 1300 may operate in mudpulse mode by default. Mud pulse mode is able to operate over a widerrange of lithological conditions due to its formation independence. Mudpulse telemetry may refer to a system of using valves to modulate theflow of drilling fluid in a bore of the drillstring. The valverestriction can generate a pressure pulse that propagates up the columnof fluid inside the drillstring and then can be detected by pressuretransducers at the surface processor 100. The EM mode enables datatransmission without a continuous fluid column, providing an alternativeto negative and positive pulse systems. An EM telemetry system may referto a system that applies a differential voltage, positive and negativevoltage, across an insulative gap in the drill string. The differentialvoltage causes current to flow through the formation creatingequipotential lines that can be detected by sensors at the surface. Dueto the formation dependence, EM communication can be hindered byparticularly high and low conductivity environments. Operating in mudpulse mode by default may ensure that a communication link between thedownhole processor 1300 and the surface processor 100 is maintainedwhile the device is in operation (e.g., downhole and not at thesurface).

The downhole processor 1300 may perform a handshake operation todetermine whether an EM channel is available to communicate and switchto the EM mode if the handshake operation is successful. Operating inthe EM mode, if available, may be beneficial as it may transfer data ata faster rate than mud pulse mode in certain situations. In someembodiments, the downhole processor 1300 may continue to operate in thefirst transmission mode (e.g., mud pulse mode) by keeping a mud pulsechannel open with the surface processor 100 but may select to transmitmessages via the second transmission mode (e.g., EM mode). In someembodiments, when the downhole processor 1300 switches to the secondtransmission mode, the downhole processor 1300 may select to disconnecta channel of the first transmission mode.

The downhole processor 1300 may be any suitable processing device, suchas one or more general-purpose processing devices such as amicroprocessor, central processing unit, or the like. More particularly,the downhole processor 1300 may be a complex instruction set computing(CISC) microprocessor, reduced instruction set computing (RISC)microprocessor, very long instruction word (VLIW) microprocessor, or aprocessor implementing other instruction sets or processors implementinga combination of instruction sets. The downhole processor 1300 may alsobe one or more special-purpose processing devices such as an applicationspecific integrated circuit (ASIC), a system on a chip, a fieldprogrammable gate array (FPGA), a digital signal processor (DSP),network processor, or the like. The downhole processor 1300 isconfigured to execute instructions for performing any of the operationsand steps of any of the methods discussed herein. The downhole processor1300 may operate in several transmission modes. For example, thedownhole processor 1300 may be communicatively coupled with the EMtransceiver 1310 and/or the MP transceiver 1311 and may use thetransceivers 1310 and/or 1311 to operate in the EM mode and/or the mudpulse mode.

The memory 1302 may be any suitable memory device, such as a tangible,non-transitory computer-readable medium storing instructions. Theinstructions may implement any operation or steps of any of the methodsdescribed herein. The downhole processor 1300 may be communicativelycoupled to the memory 1302 and may execute the instructions to performany operation or steps of any of the methods described herein.

The sensor 1304 may be any suitable sensor. In some embodiments, thesensor 1304 may be an accelerometer, velocity sensor, proximity probe,laser displacement sensor, or any suitable sensor configured to measurevibrations. The sensor 1304 may obtain vibration measurements and usethem to determine an amount of fluid flow. The sensor 1304 may transmitthe vibration measurements to the downhole processor 1300. The downholeprocessor 1300 and/or the sensor 1304 may be configured to determine theamount of fluid flow based on the measurements. Other techniques fordetermining fluid flow may be employed by the downhole processor 1300.In some embodiments, the downhole processor 1300 may be configured toswitch from the second transmission mode (e.g., EM mode) to the firsttransmission mode (e.g., mud pulse mode) when the amount of fluid flowis below a threshold amount. When the amount of fluid flow is below thethreshold amount, the mud is not being pumped and drilling is notoccurring. Such a scenario may be beneficial to switch to the firsttransmission mode to ensure connectivity with the surface processor 100is maintained. In some embodiments, the downhole processor 1300 mayswitch between transmission modes by sending control signals to arespective transceiver (e.g., EM transceiver 1310 or MP transceiver1311) associated with the desired transmission mode. The control signalmay cause a handshake message or any suitable message to be transmittedfrom the respective transceiver to the surface processor 100. In someembodiments, for example, when an EM response message is received by theEM transceiver 1310 from the surface processor 100, the downholeprocessor 1300 may switch to operating in the second transmission mode(EM mode).

FIG. 13B is another block diagram of various electronic componentsincluded in an electronic control module, according to embodiments ofthe disclosure. The electronic components included in the electroniccontrol module 15 of FIG. 13B are the same as the electronic componentsincluded in the electronic control module 15 of FIG. 13A. However, asdepicted in FIG. 13A, the EM transceiver 1310 and the MP transceiver1311 are included as components of the downhole processor 1300 in theelectronic control module 15.

FIG. 14 illustrates example operations of a method 1400 for performing ahandshake operation to switch transmission modes of a downhole device14, according to embodiments of the disclosure. Method 1400 includesoperations performed by processors of a computing device (e.g., thedownhole processor 1300 of FIG. 13A, FIG. 13B, and/or the processor 1006of FIG. 10) and/or transceivers of a computing device (e.g., EMtransceiver 1310 and/or MP transceiver 1311 of FIG. 13A, 13B). In someembodiments, one or more operations of the method 1400 are implementedin computer instructions that are stored on a memory device (e.g., thememory 1302) and executed by a processing device. The method 1400 may beperformed in the same or a similar manner as described above in regardsto method 1100. The operations of the method 1400 may be performed insome combination with any of the operations of any of the methodsdescribed herein.

At block 1402, the processing device (e.g., downhole processor 1300) mayoperate in a first transmission mode by default. The first operatingmode may be mud pulse mode. The processing device may be communicativelycoupled to an uphole processor (e.g., surface processor 100).

The processing device may generate a message. The processing device maybe communicatively coupled to the transceiver 1306 of the contact module12 and may command the transceiver to send the message using a wirelessprotocol to the uphole processor. At block 1404, the processing devicemay transmit, via a second transmission mode (e.g., electromagnetic (EM)mode), a message to the uphole processor. The message may be a handshakemessage that has a very small data size (e.g., bits, byte) and may notinclude any information. In some embodiments, the message may be adirectional survey message. In some embodiments, the message may includelithological information about the formation in which the downhole tool14 is located. For example, one or more sensors 1304 of the downholedevice 14 may obtain measurements (e.g., rock images, temperature,angle, pressure, flow of fluid (mud), and the like) and thosemeasurements may be included in the message. In some embodiments, themessage may include information pertaining to drilling, the well, and/orthe drill bit (e.g., angle, direction, temperature, etc.).

There may be several mode “pairs” used in drilling. For example, thesecan include survey/drilling or survey/sliding/rotating. The sequencescontain different information that a driller is interested in duringthat mode of operation. In a survey/drilling pair, when the mudflowstate goes low, the downhole tool 14 takes, using the one or moresensors 1304, a survey sequence (inc, azimuth, dip angle, etc) that isfocused on directional values and tool health. When the mudflow stategoes high, the downhole tool 14 may transition to a drilling sequence(gamma, toolface) that is focused on lithological information and bitorientation.

At block 1406, the processing device may determine whether a response isreceived, via the second transmission mode, from the uphole processor.The uphole processor may receive the message and perform a handshakeoperation by transmitting the response to the processing device. In someembodiments, the response may be an acknowledgement of receiving themessage. In some embodiments, the response may include information, suchas a configuration instruction that is executed by the processing deviceto change an operational setting.

At block 1408, responsive to determining the response is received fromthe uphole processor, the processing device may switch from the firsttransmission mode to the second transmission mode. In some embodiments,in response to determining the response is not received from the upholeprocessor, the processing device may continue to operate in the firsttransmission mode. In some embodiments, the processing device maymaintain the channel connection in the first transmission mode even whenthe processing device switches to the second transmission mode. This mayreduce computing resources of switching to the first transmission modewhen the condition is satisfied that results in switching back to thefirst transmission mode from the second transmission mode.

At block 1410, the processing device may determine whether a conditionis satisfied. The condition may include whether a mud flow state is lessthan a threshold. The mud flow state may be determined based onmeasurements received from the sensor 1304. The condition may include acertain depth of the downhole device. The depth of the downhole devicemay be sent in a response from the uphole processor. The condition mayinclude a certain amount of time that has expired (e.g., any suitableamount of time that may be configured). The condition may include aconnection of a tool drill string being installed. Any combination ofthe above-described conditions may be used to trigger switching back tothe default mode (e.g., first transmission mode).

At block 1412, responsive to determining the condition is satisfied, theprocessing device may switch from the second transmission mode to thefirst transmission mode. In some embodiments, the processing device maymaintain a channel connection in the second transmission mode even whenthe processing device switches to the first transmission mode. In someembodiments, the processing device may disconnect the channel connectionin the second transmission mode when the processing device switches tothe first transmission mode.

FIG. 15 illustrates example operations of another method 1500 forperforming a handshake operation to switch transmission modes of adownhole device, according to embodiments of the disclosure. Method 1500includes operations performed by processors of a computing device (e.g.,the downhole processor 1300 of FIG. 13A, FIG. 13B, and/or the processor1006 of FIG. 10) and/or transceivers of a computing device (e.g., EMtransceiver 1310 and/or MP transceiver 1311 of FIG. 13A, 13B). In someembodiments, one or more operations of the method 1500 are implementedin computer instructions that are stored on a memory device (e.g., thememory 1302) and executed by a processing device. The method 1500 may beperformed in the same or a similar manner as described above in regardsto method 1100. The operations of the method 1500 may be performed insome combination with any of the operations of any of the methodsdescribed herein.

The operations of method 1500 may be performed in conjunction with andsubsequently to operations of the method 1400 in FIG. 14. At block 1502,responsive to determining the condition is satisfied, the processingdevice may transmit, via the second transmission mode, a second messageto the uphole processor. The second message may be an EM message. Atblock 1504, the processing device may determine whether a secondresponse is received, via the second transmission mode, from the upholeprocessor. At block 1506, responsive to determining the second responseis received from the uphole processor, the processing device may switchfrom the first transmission mode to the second transmission mode. Atblock 1508, the processing device may determine whether the condition issatisfied. The condition may be the same condition as described above.At block 1510, responsive to determining the condition is satisfied, theprocessing device may switch from the second transmission mode to thefirst transmission mode. This process may continue as the condition issatisfied. That is, each time the condition is satisfied, the processingdevice may operate in its default transmission mode, which may be themud pulse mode. In some embodiments, the default mode may beconfigurable and be any suitable mode (e.g., EM, mud pulse, etc.).

Various modifications and additions can be made to the exemplaryembodiments discussed without departing from the scope of the presentdisclosure. For example, while the embodiments described above refer toparticular features, the scope of this disclosure also includesembodiments having different combinations of features and embodimentsthat do not include all of the above described features.

The following is claimed:
 1. A system including a tool drill stringhaving a downhole device, the system comprising: a memory storinginstructions; and an uphole processor configured to execute theinstructions to: communicatively couple, using a mud pulse transmissionmode, to a downhole processor included in the downhole device, whereinthe uphole processor communicatively couples to the downhole processorthrough a first transceiver included in a first component of a contactmodule, the first component is coupled to a second component of thecontact module, and the second component comprises a terminator thatelectrically isolates an external contact of the contact module from aninternal bus electrically connecting the contact module to the downholedevice; receive a handshake message sent by the downhole processor viaan electromagnetic transmission mode different than the mud pulsetransmission mode; in response to successfully receiving the handshakemessage from the downhole processor via the electromagnetic transmissionmode, transmit, while maintaining a channel with the downhole processorvia the mud pulse transmission mode, a response message via theelectromagnetic transmission mode to the downhole processor, wherein theresponse message causes the downhole processor to switch from the mudpulse transmission mode to the electromagnetic transmission mode.
 2. Thesystem of claim 1, wherein the downhole processor is further to:determine whether a condition is satisfied; responsive to determiningthe condition is satisfied, switch from the electromagnetic transmissionmode to the mud pulse transmission mode.
 3. The system of claim 2,wherein the condition comprises: a mud flow state being less than athreshold, a depth of the downhole device, an amount of time that hasexpired, a connection of a tool drill string being installed, or somecombination thereof.
 4. The system of claim 2, wherein the downholeprocessor is further to: responsive to determining the condition issatisfied, transmit, via the electromagnetic transmission mode, a secondmessage to the uphole processor; determine whether a second response isreceived, via the electromagnetic transmission mode, from the upholeprocessor; and responsive to determining the second response is receivedfrom the uphole processor, switch from the mud pulse transmission modeto the electromagnetic transmission mode.
 5. The system of claim 4,wherein the downhole processor is further to: determine whether thecondition is satisfied; and responsive to determining the condition issatisfied, switch from the electromagnetic transmission mode to the mudpulse transmission mode.
 6. The system of claim 1, wherein the downholeprocessor is further to: responsive to determining the handshake messageis not received from the uphole processor, continue operating in the mudpulse transmission mode.
 7. The system of claim 1, wherein the handshakemessage comprises a directional survey in which the downhole device islocated.
 8. The system of claim 1, wherein the downhole processor isfurther to continue operating in the mud pulse transmission mode afterswitching to the electromagnetic transmission mode and select to use theelectromagnetic transmission mode while the mud pulse transmission modeis unused.
 9. A method for operating an uphole processor and a downholedevice included in a tool drill string, the method comprising:communicatively coupling, using a mud pulse transmission mode, theuphole processor to a downhole processor included in the downholedevice, wherein the uphole processor communicatively couples to thedownhole processor through a first transceiver included in a firstcomponent of a contact module, the first component is coupled to asecond component of the contact module, and the second componentcomprises a terminator that electrically isolates an external contact ofthe contact module from an internal bus electrically connecting thecontact module to the downhole device; receiving, at the upholeprocessor, a handshake message sent by the downhole processor via anelectromagnetic transmission mode different than the mud pulsetransmission mode; in response to successfully receiving the handshakemessage from the downhole processor via the electromagnetic transmissionmode, transmitting, while maintaining a channel with the downholeprocessor via the mud pulse transmission mode, a response message viathe electromagnetic transmission mode to the downhole processor, whereinthe response message causes the downhole processor to switch from themud pulse transmission mode to the electromagnetic transmission mode.10. The method of claim 9, further comprising: determining whether acondition is satisfied; responsive to determining the condition issatisfied, switching from the electromagnetic transmission mode to themud pulse transmission mode.
 11. The method of claim 10, wherein thecondition comprises: a mud flow state being less than a threshold, adepth of the downhole device, an amount of time that has expired, aconnection of a tool drill string being installed, or some combinationthereof.
 12. The method of claim 9, further comprising: responsive todetermining a condition is satisfied, transmitting, via theelectromagnetic transmission mode, a second message to the upholeprocessor; determining whether a second response is received, via theelectromagnetic transmission mode, from the uphole processor; andresponsive to determining the second response is received from theuphole processor, switching from the mud pulse transmission mode to theelectromagnetic transmission mode.
 13. The method of claim 12, furthercomprising: determining whether the condition is satisfied; responsiveto determining the condition is satisfied, switching from theelectromagnetic transmission mode to the mud pulse transmission mode.14. The method of claim 9, further comprising: responsive to determiningthe handshake message is not received from the uphole processor,continuing to operate in the mud pulse transmission mode.
 15. The methodof claim 9, wherein the handshake message comprises a survey includinglithological information of a formation in which the downhole device islocated.
 16. A tangible, non-transitory computer-readable medium storinginstructions that, when executed, cause a processing device to:communicatively couple, using a mud pulse transmission mode, an upholeprocessor to a downhole processor included in a downhole device, whereinthe uphole processor communicatively couples to the downhole processorthrough a first transceiver included in a first component of a contactmodule, the first component is coupled to a second component of thecontact module, and the second component comprises a terminator thatelectrically isolates an external contact of the contact module from aninternal bus electrically connecting the contact module to the downholedevice; receive a handshake message sent by the downhole processor viaan electromagnetic transmission mode different than the mud pulsetransmission mode; in response to successfully receiving the handshakemessage from the downhole processor via the electromagnetic transmissionmode, transmit, while maintaining a channel with the downhole processorvia the mud pulse transmission mode, a response message via theelectromagnetic transmission mode to the downhole processor, wherein theresponse message causes the downhole processor to switch from the mudpulse transmission mode to the electromagnetic transmission mode.